US9988894B1 - System and method for installing a power line in a well - Google Patents
System and method for installing a power line in a well Download PDFInfo
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- US9988894B1 US9988894B1 US14/627,904 US201514627904A US9988894B1 US 9988894 B1 US9988894 B1 US 9988894B1 US 201514627904 A US201514627904 A US 201514627904A US 9988894 B1 US9988894 B1 US 9988894B1
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- power line
- powered device
- electrical connector
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- 238000000034 method Methods 0.000 title claims abstract description 25
- 238000004519 manufacturing process Methods 0.000 claims description 41
- 239000012530 fluid Substances 0.000 claims description 11
- 238000005086 pumping Methods 0.000 claims description 9
- 230000008859 change Effects 0.000 claims description 4
- 238000012544 monitoring process Methods 0.000 claims description 2
- 238000009434 installation Methods 0.000 abstract description 15
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Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/02—Determining slope or direction
- E21B47/024—Determining slope or direction of devices in the borehole
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/023—Arrangements for connecting cables or wirelines to downhole devices
- E21B17/025—Side entry subs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
- E21B43/121—Lifting well fluids
- E21B43/128—Adaptation of pump systems with down-hole electric drives
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- E21B47/065—
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
- F04B17/00—Pumps characterised by combination with, or adaptation to, specific driving engines or motors
- F04B17/03—Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by electric motors
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
- F04B—POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS
- F04B47/00—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps
- F04B47/06—Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
Definitions
- This invention relates to a system and method for installing a power line in a well.
- the present invention relates to improved ways of installing a tube with an electrical connection from the power line to a powered device located in the tube.
- Electric submersible pump (ESP) systems are typically installed in oil and gas wells where reservoir pressure is inadequate to lift reservoir fluids to the surface or to increase production in natural producing wells. As a reservoir is produced, the pressure in the pore space of the rocks decreases, and thus may require the introduction of some type of artificial lift system to continue production as a reservoir or a well ages.
- An ESP system provides an artificial lift for a reservoir and/or well and comprises a motor to convert electrical power from a cable to mechanical power to drive the pump.
- a production tube with a power line attached is typically installed into a completed well so that one or more powered device of the ESP system can be connected to the power line for a number of purposes.
- a remote electrical connection means also known as a wet connector or wet connect
- Connection of a powered device to the installed power line via a wet connector may be designed to take place at any point along the length of the well but is typically positioned at the lower or furthest end of the well.
- the wet connector is a sensitive electromechanical device and is arranged at the lower end of the production tube and is usually installed with the powered device to form a bottom hole assembly (BHA).
- BHA bottom hole assembly
- This BHA is prone to damage and/or debris agglomeration during installation, particularly when deployed into a deviated or horizontal well.
- the wet connector arrangement typically requires a plug arm protruding into a window in the production tubing to enable it to be selectively electrically connected to the power line. This window increases the vulnerability of the wet connector as it is prone to permit access for an increase of debris accumulation in the vicinity of the wet connector.
- the scribe line is carefully monitored to keep track of the orientation of the scribe line at the bottom of the tubing string. As the bottom of the tubing string approaches the final depth setting the tubing string is rotated at the surface to place the scribe line in the correct position to orient the completion in the desired direction.
- This method is simple and inexpensive but the accuracy is poor and the opportunity for an error is very high, as small errors can accumulate and become large ones.
- a system for installing a powerline in a well comprising a power line disposed along a tube, the power line comprising a lower end and a first power connector located in a fixed circumferential position on the tube, and arranged to be accessible for connection with a corresponding second power connector on a powered device, and a sensor provided in the proximity of and coupled to the first power connector for transmitting signals back along the power line during the installation of the power line and the tube.
- the sensor preferably includes an orientation sensor which determines the circumferential orientation of the tube and hence the circumferential position of the first power connector.
- an orientation sensor which determines the circumferential orientation of the tube and hence the circumferential position of the first power connector.
- a method is contemplated to rotate the tube in horizontal or partially horizontal portions of the well so that the first power connector is maintained in the most upwardly position during installation.
- a method for installing a powered device in a well comprising disposing a power line along a tube, terminating the power line in a first power connector located in a circumferential position on the tube, providing an assembly including a powered device and a second power connector, lowering the tube and power line inside the well to a desired location and rotating the tube circumferentially relatively to the well, the orientation according to data provided by an orientation sensor which detects the orientation of the tube relative to circumferential position of the well and generates a corresponding signal which is transmitted so that the first power connector is aligned upwardly in the non-vertical portions of the well during installation.
- an orientation measuring device or directional sensory system in which the sensors may be selected from a group including but not limited to accelerometers, magnetometers, gyros, acoustic, vibrational or radiation distance sensors, or other direction sensors.
- the sensor may be as part of (or attached to) a retrievable electric submersible pump (ESP) completion, with the pump being the powered device.
- the pump and sensor system may be deployed together when the completion is being installed.
- the ESP completion system preferably contains an ESP cable, as part of the outer completion, which provides the ESP and sensory system with power and a path to transfer data up to the surface.
- the ESP inner completion systems being the pump, motor and the inner wet connection, can be removed and reinstalled at any time.
- the sensor as an integral part of the outer completion or pump can, can provide many types of useful data about the cable, wet connect and downhole environment. Information such as orientation, temperature and pressure can be valuable during installation, removal or reinstallation.
- the sensory system is used to provide information about the orientation of the ESP completion in real-time as it is being installed and transmits this information up to the surface via the ESP cable.
- the ESP cables provide a simple and reliable communication (as well as power) link between the surface and the ESP completion. Additional measurements may be added to this system to provide real-time monitoring and control of the installation process to improve efficiency and safety.
- additional sensors can be added to provide information on the fluid properties, well conditions as well as status and activation of downhole components.
- the production tubing of the ESP is installed with a wet connector with the possibility of connecting a motor post-installation.
- FIG. 1 shows a longitudinal cross section showing the bore hole assembly portion of the system of the invention in a well in accordance with at least some embodiments
- FIG. 2 shows a schematic view of a bore hole showing a general arrangement of an embodiment of the system of the invention in a well in accordance with at least some embodiments;
- FIG. 3 shows an enlarged longitudinal section view of the lower end of the production tubing in accordance with at least some embodiments
- FIG. 4 shows an enlarged longitudinal section showing an alternative embodiment of the system of the invention at the lower end of the production tubing in accordance with at least some embodiments.
- the terms “including” and “comprising” are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .”
- the term “couple” or “couples” is intended to mean either an indirect or direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection or through an indirect electrical connection via other devices and connections.
- the ESP completion 1 is installed in the well or well casing 8 along with a large power line (ESP cable) 2 that provides electric power to the ESP system after installation.
- ESP cable large power line
- the downhole end of this power line 2 is connected to a wet connector 3 , the opposite end of the power line 2 runs to a variable speed drive (VSD) 4 at the surface.
- VSD variable speed drive
- the wet connector 3 comprises a first male connector 10 and a second female connector 11 which is electrically coupled to a powered device 12 .
- the power line 2 As production tubing 6 is installed into the well (from tube installation means not shown), the power line 2 is spooled off of a large reel 5 , and loops around an installation sheave 7 and is attached to the outside of the production tubing 6 , by means of cable clamps or the like (not shown).
- the production tubing can either be continuous coiled tubing or jointed tubing connected together to sections.
- the power line 2 may be pre-attached to the outside of the production tubing 6 .
- an electric submersible pump (or ESP) comprises a number of pump modules 23 , located above a number of motor modules 22 , also known as ESP motors.
- the pumps 23 and the motors 22 are connected in series, with, in this embodiment, the pumps 23 situated upstream of the motors 22 .
- the relative positions may be referred to as above or below, showing the relation as shown in figures whereas in reality the well may well be horizontal so reference to upstream and downstream is also used.
- the lowermost pump 23 includes a pump inlet 21 also known as an ESP housing inlet, and a pump outlet (not shown) is situated above an engageable seal 20 .
- the electric submersible pump is lowered down the production tithe 6 on a wireline 19 to the correct position.
- a plug arm from the wet connector 3 extends from the electric submersible pump string to project through an opening in the permanent completion 6 a and engage with the power line 2 .
- the wet connector 3 and the power line 2 may mate using a known mechanism such as that described in UK patent GB2403 490, the complete disclosure of which is incorporated herein by reference.
- the pump 23 and ESP motor 22 can be installed with the production tubing 6 in which case the motor is already connected to the power line 2 and the wet connector 3 is already deployed and connected.
- the pump 23 and ESP motor 22 may be retrieved at any later time by the wireline 19 for replacement or maintenance.
- the wireline 19 need not remain in place but can be deployed when required and automatically connect to the pump 23 by suitable connection means.
- the powered device 12 being a motor and pump, and permanent completion 6 a and cable 2 are deployed simultaneously and is known as an ESP (electric submersible pump) completion 1 .
- This ESP completion 1 has two key subsystems, the bottom hole assembly (BHA) or outer completion 15 and the inner completion 14 .
- the BHA 15 consists of two primary components, the housing portion of the lower end of the production tubing, known as the pump can 16 and the male portion 10 of the wet connector 3 .
- the wet connector 3 is a three phase electrical connector that can be mated while submerged in well fluid.
- the male portion 10 of the wet connect 3 is connected to the ESP cable 2 which extends to the surface.
- the inner completion 14 includes the female portion 11 of the wet connector 3 , the powered device 12 (i.e., the pump and motor) and the plug arm 24 .
- Inner completion 14 may be installed simultaneously with the production tubing 6 and cable 2 or it can be installed into the BHA by deploying it through the production tubing with a wireline, slickline, coiled tubing or a tractor after the production tubing is installed.
- the inner completion 14 includes a fishing head or other similar mechanism to allow removal of the inner completion 14 system from the BHA 15 using conventional oilfield service tools. To achieve this removal the inner completion 14 is first moved downwardly, away from the surface, left to right in FIG. 3 , to disconnect the female connector 11 from the male connector 10 .
- the plug arm 24 then automatically retracts the female connector 11 inwardly to the body of the inner completion 14 , following which the entire inner completion 14 may be pulled towards the surface, from right to left in FIG. 3 .
- the inventors of the present specification have found a shortcoming of related-art devices in the form of variable electrical connectivity alignment and positioning between the surface power supply and the powered devices 12 based on the orientation of the wet connect 3 within the production tubing 6 .
- orientation of the components in a tubing string such as electrically coupled devices in an ESP system, is mechanically determined, by scribing or by the use of other mechanical features.
- the issues associated with the orientation of the wet connect within the production tubing are addressed, at least in part, by a system and related method which senses changes in orientation of the wet connect 3 and automatically (i.e., without human involvement at the time of the change) transmits data to the surface indicative of the position of the wet connect.
- sensor 9 is provided between the end of the power line 2 and the first wet connector 10 .
- the sensor system 9 can be located in either the BHA 15 as shown in FIG. 4 , or the inner completion 14 as shown in FIG. 3 .
- This sensor 9 includes an orientation measuring device which remains connected to the power line 2 while the power line 2 and tubing 6 is being installed in the well.
- the sensor system 9 houses one or more of the following sensors and the associated electronics: accelerometers, magnetometers, gyro sensors, pressure sensors, casing collar locators, fluid property sensors, temperature sensors, current sensor, inclinometer, and/or gyroscope.
- the orientation sensor may take many forms.
- the sensor 9 is an inclinometer that provides analog and digital values indicative of the relative positions of the wet connect 3 and the production tube 6 .
- an inclinometer as the orientation sensor 9 may not provide the ability to sense elevation changes (with constant inclination) or sense rotational orientation changes.
- the orientation sensor 9 may be implemented with a digital gyroscope. Using a three-axis gyroscope the system may be able to sense not only changes in inclination of the wet connect 3 , but also sense changes in elevation of the wet connect 3 —that is, sense changes in all three spatial directions.
- the orientation sensor 9 may be a six-axis gyroscope, which is a device that implements a three-axis gyroscope as well as a corresponding three-axis accelerometer. By combining the readings of the gyroscope and accelerometer, more accurate measurements of orientation may be provided.
- the sensor system 9 could be located above or below the wet connector 10 , that is to say either closer to the surface or further from the surface.
- this orientation measuring device 9 which remains connected to the power line 2 , transmits data indicative of the orientation (along with other desired data and measurements) to the surface acquisition system 18 through the power line 2 as it is being spooled into the well.
- orientation sensor 9 may be communicatively coupled to data acquisition system 18 by way of conductors associated with power line 2 .
- communicative coupling scenarios possible with respect to acquisition system 18 and sensor 9 , which depend in part on the type of sensor used.
- the communication from the sensor may be by way of analog signal, in which case the system would comprise electrical connection to an analog-to-digital input (not specifically shown).
- the communication between the sensor 9 and the acquisition system 18 may be a digital serial communication. Regardless of how the acquisition system 18 and sensor 9 are communicatively coupled, by reading data indicative of the environment in the vicinity of the sensor 9 the acquisition system 18 may provide data and information regarding the status of the BHA 15 .
- This data provides a continuous measurement of the orientation of the tubing 6 (and the associated components mounted to the tubing) so that they can be accurately placed in the desired orientation in addition to providing data relevant to other diagnostic and fluid/well/reservoir measurements.
- the production tubing 6 can be orientated such that the first connection means 10 is in an uppermost position in the well and therefore is out of the way of any debris that may have accumulated in the horizontal portion of the well and resting on the lowermost part 13 of the horizontal portion of the well.
- the BHA 15 is installed in a horizontal well it is very desirable to run the BHA 15 with the wet connector 3 towards the “top side” of the hole (zero degree tool face) and to set the BHA 15 with the wet connector 3 to the uppermost “high” side of the hole.
- Data from sensor 9 can provide information to the surface that the wet connector 3 is indeed positioned in the desired orientation.
- the inner completion 14 when the inner completion 14 is to be installed it is lowered, or otherwise urged to the desired position in the production tubing, precise alignment of the inner completion 14 to the BHA 15 is achieved both radially and longitudinally by means of the data acquired from sensor 9 .
- orientation data is provided to orient the sensor 9 to the desired circumferential position.
- the inner completion 14 may include other components such as gauges, packers, safety valves, etc., which can be aligned with the BHA 15 during installation of the inner completion 14 .
- the system By collecting and utilizing sensor data from the orientation device 9 to manage the orientation of the BHA 15 , the system enables a user to monitor and position other sensitive or delicate completion components and adjust these components so that they are oriented along with the BHA 15 .
- the plug arm 24 Upon gathering data that indicates the system is positioned in the desired orientation, the plug arm 24 extends outwardly and aligns the wet connect 11 , permitting establishment of electrical continuity with the male wet connector 10 of the power line 2 .
- the wet connect/orientation system could also include electronic circuits to interface between the ESP cable and the sensor package before physical electrical connection is complete. Alternatively, or additionally a mechanism can be provided (not shown) to allow connection/disconnection of the sensor 9 from the inner completion 12 , so it can be installed and retrieved from the inner completion 12 using slickline, coiled tubing, tractors, sucker rods or other retrieval methods at any time before, during or after installation of the production string and BHA 15 .
- the sensor package 9 and wet connect/orientation unit are installed into the BHA 15 (this installation can take place at any time due to the availability of the wet connect).
- the sensor 9 measures the orientation of the BHA 15 and, depending on the configuration of the various possible types of sensors included, it can also include measurements of the down-hole pressure, fluid content, temperature or other diagnostic measurements. This information passes through the wet connect/orientation unit and the wet connector to the power line 2 . It is then passed through the power line 2 until it reaches the surface and is provided to the acquisition system 18 for processing, display, and other forms of data usage by the user.
- the sensor 9 can be mounted inside the BHA 15 housing on a permanent basis as shown in FIG. 4 .
- the sensor 9 can measure and transmit data to the surface through the power line 2 .
- the data can include orientation of the BHA 15 (measured using accelerometers, magnetometers or other directional sensors), intake and discharge pressure of the pumping system, temperature of the motor winding, fluid property sensors, annular pressure sensors, vibration and other measurements to improve system efficiency, provide reservoir control and to assist with diagnostics of problems with the system.
- This system could also be used to control and sense the position of downhole valves to provide pressure control during and after deployment.
- this system may be used to detect damage to power line 2 before deployment of motor 22 .
- sensor 9 may comprise a current sensor located to detect a nominal current value associated with energy delivered through power line 2 , and thereby confirm whether power line 2 is free of damage or an electrical short prior to deploying and electrically coupling motor 22 to power line 2 .
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Abstract
Description
Claims (21)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
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US14/627,904 US9988894B1 (en) | 2014-02-24 | 2015-02-20 | System and method for installing a power line in a well |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US201461943539P | 2014-02-24 | 2014-02-24 | |
US14/627,904 US9988894B1 (en) | 2014-02-24 | 2015-02-20 | System and method for installing a power line in a well |
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US9988894B1 true US9988894B1 (en) | 2018-06-05 |
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US14/627,904 Active 2035-08-09 US9988894B1 (en) | 2014-02-24 | 2015-02-20 | System and method for installing a power line in a well |
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Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10533381B2 (en) * | 2016-09-05 | 2020-01-14 | Coreteq Systems Limited | Wet connection system for downhole equipment |
US11073016B2 (en) * | 2019-12-02 | 2021-07-27 | Halliburton Energy Services, Inc. | LWD formation tester with retractable latch for wireline |
US11073012B2 (en) | 2019-12-02 | 2021-07-27 | Halliburton Energy Services, Inc. | LWD formation tester with retractable latch for wireline |
WO2022192669A1 (en) * | 2021-03-12 | 2022-09-15 | Schlumberger Technology Corporation | Downhole connector orientation for wetmate connectors |
US11795767B1 (en) | 2020-11-18 | 2023-10-24 | Schlumberger Technology Corporation | Fiber optic wetmate |
WO2024063881A1 (en) * | 2022-09-23 | 2024-03-28 | Baker Hughes Oilfield Operations Llc | Position sensor, method and system |
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